EP1960932A2 - Appareils et procédés pour une mesure multivoie de la consommation électrique - Google Patents

Appareils et procédés pour une mesure multivoie de la consommation électrique

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Publication number
EP1960932A2
EP1960932A2 EP06849894A EP06849894A EP1960932A2 EP 1960932 A2 EP1960932 A2 EP 1960932A2 EP 06849894 A EP06849894 A EP 06849894A EP 06849894 A EP06849894 A EP 06849894A EP 1960932 A2 EP1960932 A2 EP 1960932A2
Authority
EP
European Patent Office
Prior art keywords
pic
status
comm
data
operable
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Granted
Application number
EP06849894A
Other languages
German (de)
English (en)
Other versions
EP1960932B1 (fr
EP1960932A4 (fr
Inventor
Sayre A. Swarztrauber
Doron Shafrir
Siddharth Malik
Robert Hayward
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Quadlogic Controls Corp
Original Assignee
Quadlogic Controls Corp
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Priority claimed from US11/431,849 external-priority patent/US7539581B2/en
Application filed by Quadlogic Controls Corp filed Critical Quadlogic Controls Corp
Priority to PL06849894T priority Critical patent/PL1960932T3/pl
Publication of EP1960932A2 publication Critical patent/EP1960932A2/fr
Publication of EP1960932A4 publication Critical patent/EP1960932A4/fr
Application granted granted Critical
Publication of EP1960932B1 publication Critical patent/EP1960932B1/fr
Not-in-force legal-status Critical Current
Anticipated expiration legal-status Critical

Links

Classifications

    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01R—MEASURING ELECTRIC VARIABLES; MEASURING MAGNETIC VARIABLES
    • G01R22/00—Arrangements for measuring time integral of electric power or current, e.g. electricity meters
    • G01R22/06—Arrangements for measuring time integral of electric power or current, e.g. electricity meters by electronic methods
    • G01R22/061—Details of electronic electricity meters
    • G01R22/066—Arrangements for avoiding or indicating fraudulent use
    • H—ELECTRICITY
    • H04—ELECTRIC COMMUNICATION TECHNIQUE
    • H04Q—SELECTING
    • H04Q9/00—Arrangements in telecontrol or telemetry systems for selectively calling a substation from a main station, in which substation desired apparatus is selected for applying a control signal thereto or for obtaining measured values therefrom
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01R—MEASURING ELECTRIC VARIABLES; MEASURING MAGNETIC VARIABLES
    • G01R22/00—Arrangements for measuring time integral of electric power or current, e.g. electricity meters
    • G01R22/06—Arrangements for measuring time integral of electric power or current, e.g. electricity meters by electronic methods
    • G01R22/061—Details of electronic electricity meters
    • G01R22/063—Details of electronic electricity meters related to remote communication
    • H—ELECTRICITY
    • H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
    • H02J—CIRCUIT ARRANGEMENTS OR SYSTEMS FOR SUPPLYING OR DISTRIBUTING ELECTRIC POWER; SYSTEMS FOR STORING ELECTRIC ENERGY
    • H02J13/00—Circuit arrangements for providing remote indication of network conditions, e.g. an instantaneous record of the open or closed condition of each circuitbreaker in the network; Circuit arrangements for providing remote control of switching means in a power distribution network, e.g. switching in and out of current consumers by using a pulse code signal carried by the network
    • H02J13/00006—Circuit arrangements for providing remote indication of network conditions, e.g. an instantaneous record of the open or closed condition of each circuitbreaker in the network; Circuit arrangements for providing remote control of switching means in a power distribution network, e.g. switching in and out of current consumers by using a pulse code signal carried by the network characterised by information or instructions transport means between the monitoring, controlling or managing units and monitored, controlled or operated power network element or electrical equipment
    • H02J13/00007—Circuit arrangements for providing remote indication of network conditions, e.g. an instantaneous record of the open or closed condition of each circuitbreaker in the network; Circuit arrangements for providing remote control of switching means in a power distribution network, e.g. switching in and out of current consumers by using a pulse code signal carried by the network characterised by information or instructions transport means between the monitoring, controlling or managing units and monitored, controlled or operated power network element or electrical equipment using the power network as support for the transmission
    • H—ELECTRICITY
    • H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
    • H02J—CIRCUIT ARRANGEMENTS OR SYSTEMS FOR SUPPLYING OR DISTRIBUTING ELECTRIC POWER; SYSTEMS FOR STORING ELECTRIC ENERGY
    • H02J13/00—Circuit arrangements for providing remote indication of network conditions, e.g. an instantaneous record of the open or closed condition of each circuitbreaker in the network; Circuit arrangements for providing remote control of switching means in a power distribution network, e.g. switching in and out of current consumers by using a pulse code signal carried by the network
    • H02J13/00032—Systems characterised by the controlled or operated power network elements or equipment, the power network elements or equipment not otherwise provided for
    • H02J13/00034—Systems characterised by the controlled or operated power network elements or equipment, the power network elements or equipment not otherwise provided for the elements or equipment being or involving an electric power substation
    • H—ELECTRICITY
    • H04—ELECTRIC COMMUNICATION TECHNIQUE
    • H04Q—SELECTING
    • H04Q2209/00—Arrangements in telecontrol or telemetry systems
    • H04Q2209/30—Arrangements in telecontrol or telemetry systems using a wired architecture
    • H—ELECTRICITY
    • H04—ELECTRIC COMMUNICATION TECHNIQUE
    • H04Q—SELECTING
    • H04Q2209/00—Arrangements in telecontrol or telemetry systems
    • H04Q2209/60—Arrangements in telecontrol or telemetry systems for transmitting utility meters data, i.e. transmission of data from the reader of the utility meter
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02E—REDUCTION OF GREENHOUSE GAS [GHG] EMISSIONS, RELATED TO ENERGY GENERATION, TRANSMISSION OR DISTRIBUTION
    • Y02E60/00—Enabling technologies; Technologies with a potential or indirect contribution to GHG emissions mitigation
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y04—INFORMATION OR COMMUNICATION TECHNOLOGIES HAVING AN IMPACT ON OTHER TECHNOLOGY AREAS
    • Y04S—SYSTEMS INTEGRATING TECHNOLOGIES RELATED TO POWER NETWORK OPERATION, COMMUNICATION OR INFORMATION TECHNOLOGIES FOR IMPROVING THE ELECTRICAL POWER GENERATION, TRANSMISSION, DISTRIBUTION, MANAGEMENT OR USAGE, i.e. SMART GRIDS
    • Y04S40/00—Systems for electrical power generation, transmission, distribution or end-user application management characterised by the use of communication or information technologies, or communication or information technology specific aspects supporting them
    • Y04S40/12—Systems for electrical power generation, transmission, distribution or end-user application management characterised by the use of communication or information technologies, or communication or information technology specific aspects supporting them characterised by data transport means between the monitoring, controlling or managing units and monitored, controlled or operated electrical equipment
    • Y04S40/121—Systems for electrical power generation, transmission, distribution or end-user application management characterised by the use of communication or information technologies, or communication or information technology specific aspects supporting them characterised by data transport means between the monitoring, controlling or managing units and monitored, controlled or operated electrical equipment using the power network as support for the transmission

Definitions

  • One embodiment of the present invention comprises a metering device that is related to the Quadlogic ASIC-based family of meters (see U.S. Pat. No. 6,947,854, and U.S. Pat. App. Pub. No. 20060036388, the entire contents of which are incorporated herein by reference).
  • this embodiment (referred to herein for convenience as "Energy Guard”) is a multi-channel meter that preferably is capable of providing much of the functionality of the above-mentioned family of meters, and further provides the improvements, features, and components listed below.
  • a MiniCloset is a 24-channel metering device that can measure electric usage for up to 24 single-phase customers, 12 two- phase customer, or 8 three-phase customers.
  • Preferably connected to the MiniCloset are one or more Load Control Modules (LCMs), discussed below.
  • LCMs Load Control Modules
  • Energy Guard preferably comprises a MiniCloset meter head module and two LCMs mounted into a steel box. Relays that allow for an electricity customer to be remotely disconnected and reconnected, along with current transformers, also are mounted into the box. See FIG. 1. Upon installation, an electricity customer's electricity supply line is tapped off the main electric feeder, passed through the Energy Guard apparatus, and run directly to the customer's home. The construction and usage of the Energy Guard will be apparent to those skilled in the art upon review of the description below and related figures. Source code is supplied in the attached Appendix.
  • Energy Guard meters preferably are operable to provide:
  • the meter supports full duplex (bi- directional) communication via power line communication (“PLC”) and may be equipped with remotely operated relays (60 amp, 100 amp, or 200 amp) that allow for disconnect and reconnect of electric users remotely.
  • PLC power line communication
  • Theft Prevention The system is designed with three specific features to prevent theft. First, an Energy Guard apparatus preferably is installed on a utility pole above the medium-tension lines, making it difficult for customers to reach and tamper with. Second, because there are no additional signal wires with the system (i.e., all communication is via the power line), any severed communication wires are immediately detectable. That is, if a communication wire is cut, service is cut, which is readily apparent.
  • a third theft prevention feature is that the meter may be used to measure the transformer energy in order to validate the measured totals of individual clients. Discrepancies can indicate theft of power.
  • the Energy Guard preferably provides two modes of optical tamper detection. Each unit contains a light that reflects against a small mirror-like adhesive sticker. The absence of this reflective light indicates that the box has been opened. This detection will automatically disconnect all clients measured by that Energy Guard unit. In addition, if the Energy Guard enclosure is opened and ambient light enters, this will also automatically disconnect all clients measured by that Energy Guard unit. These two modes of tamper detection are continuously engaged and alternate multiple times per second for maximum security.
  • D Reverse Voltage Detection: In some cases, a utility company can disconnect power to an individual client and that client is able to obtain power via an alternative feed.
  • Pre-payment for energy can be done via phone, electronic transaction, or in person. The amount of kWh purchased is transmitted to the meter and stored in its memory. The meter will count down, showing how much energy is still available before reaching zero and disconnecting. As long as the customer continues to purchase energy, there will be no interruption in service, and the utility company will have a daily activity report.
  • Energy Guard meters can allow the utility to remotely limit the power delivered to a set level, disconnecting when that load is exceeded. If the customer exceeds that load and is disconnected, the customer can reset a button on the optional remote display unit to restore load as long as the connected load is less than the pre-set limit. Alternatively, clients can call an electric utility service line by telephone to have the service restored. This feature allows electric utilities to provide electricity for critical systems even, for example, in the case of a non-paying customer.
  • the Energy Guard firmware is capable of shutting down power when a certain consumption level is reached. However, this type of program is best implemented when advanced notification to customers is provided. This can be achieved either with a display in the home whereby a message or series of messages notifies customers that their rate of consumption is approaching the projected consumption for the month.
  • timed service interruptions can be programmed so that as the limit is approaching, power is disconnected for periods of time with longer and longer increments to notify the residents. These planned interruptions in service act as a warning to customers that their limit is nearing so that they have time to alter their consumption patterns.
  • (H) Meter Validation The integrated module of the system preferably is removable. This permits easy laboratory re-validation of meter accuracy in the event of client billing disputes.
  • the invention comprises a device for measuring electricity usage, comprising: means for remote disconnection via power line communication; means for detection of electricity theft; means for tamper detection; and means for reverse voltage detection.
  • the invention comprises an apparatus for multi-channel metering of electricity, comprising: (a) a meter head operable to measure electricity usage for a plurality of electricity consumer lines; (b) a transponder in communication with the meter head and operable to transmit data received from the meter head via power line communication to a remotely located computer, and to transmit data received via power line communication from the remotely located computer to the meter head; and (c) a load control module in communication with the meter head and operable to actuate connection and disconnection of each of a plurality of relays, each relay of the plurality of relays corresponding to one of the plurality of electricity consumer lines.
  • the apparatus further comprises a tamper detector in communication with the meter head; (2) the tamper detector comprises a light and a reflective surface, and the meter head is operable to instruct the load control module to disconnect all of the customer lines if the tamper detector provides notification that the light is not detected reflecting from the reflective surface; (3) the apparatus further comprises a box containing the meter head, the load control module, and the relays, and wherein the tamper detector comprises a detector of ambient light entering the box; (4) the apparatus further comprises a box containing the meter head, the load control module, and the relays, and wherein the box is installed on a utility pole; (5) the apparatus further comprises means for comparing transformer energy to total energy used by the consumer lines; (6) the apparatus further comprises means for detecting reverse voltage flow through the consumer lines; (7) the apparatus further comprises a computer readable memory in communication with the meter head and a counter in communication with the meter head, the counter corresponding to a customer line and operable to count down an
  • FIG. 1 is a block/wiring diagram showing connection of preferred embodiments.
  • FIG. 2 is a block diagram showing physical configuration of preferred embodiments.
  • FIGS. 3A-3B are schematic diagrams of a preferred CPU board of a Scan Transponder and MiniCloset.
  • FIG. 4 is a schematic diagram of a preferred Scan Transponder power supply.
  • FIG. 5 is a schematic diagram of a preferred MiniCloset power supply.
  • FIG. 6 is a schematic diagram of a preferred circuit board for returning current transformer information to a MiniCloset meter head.
  • FIGS. 7A-7C are schematic diagrams of a preferred Load Control Module circuit board.
  • FIGS. 8A-8D are schematic diagrams of a preferred power supply board that provides for optical tamper detection.
  • FIGS. 9A-9C are schematic diagrams of a preferred Energy Guard connection board.
  • FIG. 10 is a schematic diagram for a control circuitry board operable to provide relay control.
  • FIG. 11 is a diagram of preferred Energy Guard base assembly.
  • FIGS. 12 and 13 are diagrams of preferred phase bus bars and construction of same.
  • FIG. 14 is a diagram depicting preferred neutral bar frame construction and assembly.
  • FIG. 15 depicts preferred transition bars
  • FIG. 16 depicts preferred placement of transition bars.
  • FIG. 19 depicts a preferred integrated current sensing and relay module.
  • FIG. 20 depicts an exploded view of a preferred integrated current sensing and relay module.
  • FIG. 21 shows exploded views of preferred metering modules.
  • FIG. 22 shows the metering modules placed in an EG frame assembly and acceptor module.
  • FIG. 23 shows an exploded view a preferred embodiment of Energy Guard.
  • FIG. 24 shows an exploded view of a preferred EG assembly and base assembly.
  • FIG. 25 shows a preferred EG layout.
  • FIGS. 26 and 27 are preferred metering module schematics.
  • FIG. 28 has preferred schematics for a back place board.
  • FIG. 29 has preferred schematics for a power board.
  • FIG. 30 has preferred schematics for an I/O extension board.
  • FIG. 31 has preferred schematics for a CPU board.
  • FIG. 32 has preferred schematics for a control module.
  • FIG. 33 has preferred schematics for metering and power supply circuitry for a customer display module;
  • FIG. 34 has preferred schematics for a display board for the CDM.
  • FIG. 35 is a block diagram of a preferred analog front end for metering.
  • FIGS. 36 and 37 depict preferred DSP implementations.
  • FIG. 38 illustrates preferred in-phase filter frequency and implulse response characteristics.
  • FIG. 39 illustrates injecting PLC signals at half-odd harmonics of 60 Hz.
  • FIG. 40 depicts 12 possible ways in which an FFT frame received by a meter can be out of phase with a scan transponded FFT frame.
  • FIG. 41 illustrates preferred FIR filter specifications.
  • FIG. 42 depicts voltage and current resulting from, a preferred FFT.
  • an Energy Guard metering apparatus comprises a MiniCloset (that is, a metering apparatus operable to meter a plurality of customer lines); a Scan Transponder; one or more relays operable to disconnect service to selected customers; a Load Control Module; and optical tamper detection means.
  • MiniCloset and Scan Transponder referred to herein are largely the same as described in U.S. Pat. No. 6,947,854. That is, although each has been improved over the years, the functionality and structure relevant to this description may be taken to be the same as described in that patent.
  • FIG. 1 is a block diagram of connections of a preferred embodiment.
  • Medium voltage power lines A, B, C 5 and N feed into Distribution Transformer 110.
  • Low voltage lines connect (via current transformers 120) Distribution Transformer 110 to Energy Guard unit 140.
  • Energy Guard unit 140 monitors current transformers 120, and feeds single phase customer lines 1-24.
  • FIG. 2 is a block diagram of preferred structure of an Energy Guard unit 140.
  • Scan Transponder 210 is the preferred data collector for the unit 140, may be located external to or inside the MiniCloset, and may be the main data collector for more than one MiniCloset at a time.
  • the Scan Transponder 210 preferably : (a) verifies data (each communication preferably begins with clock and meter identity verification to ensure data integrity); (b) collects data (periodically it collects a data block from each meter unit, with each block containing previously collected meter readings, interval readings, and event logs); (c) stores data (preferably the data is stored in non-volatile memory for a specified period (e.g., 40 days)); and (d) reports data (either via PLC, telephone modem, RS-232 connection, or other means).
  • the slide plate 280 comprises a Minicloset meter head and a load control module 240 that provides the control signals to activate the relays. All of the electronics preferably is powered up by power supply 250.
  • the back plate assembly 270 comprises multiple (e.g., 24) Current Transformers and relays - grouped, in this example, as three sets of 8 CTs and relays. Customer cables are wired through the CTs and connect to the circuit on customer premises 290.
  • the remotely located Scan Transponder 210 accesses the Energy Guard meter head and bi-directionally communicates using power line carrier communication.
  • the signal flow shown in FIGS. 1 and 2 preferably is accomplished by implementing different software code modules that work concurrently to enable remote connect/disconnect ability in the Minicloset.
  • These software modules provided in the Appendix below, are:
  • FIGS. 3-10 are schematics of preferred components, as described below.
  • the preferred connect/disconnect relays are series K850 KG relays, but those skilled in the art will recognize that other relays may be used without departing from the scope of the invention.
  • the implementation of Energy Guard takes advantage of the similarity of architecture of traditional circuit breaker panels, with the multichannel metering environment, hi a circuit breaker panel, electricity is fed to the panel and distributed among various customer circuits via circuit breakers that provide the ability to connect or disconnect the customer circuits.
  • MiniCloset/Energy Guard multiple current transformers measure the current in customer circuits and bring this data back to a central processing unit where the metering quantities are calculated.
  • the MiniCloset/Energy Guard has several key differences with a circuit breaker panel. For example, whereas circuit breakers are found near customer premises, the Energy Guard typically is installed near the utility distribution transformer. The advantages offered by this alternate embodiment will be apparent to those skilled in the art. For example, this embodiment offers improved dimensions and overall size over the embodiments discussed above. Space is always a constraint when equipment additions are made to existing electrical installations.
  • This version of the Energy Guard (“EG”) with preferred dimensions of 28" X 22" X 11" provides a substantial advantage in situations where volumetric constraints exist.
  • this embodiment is operable to providing remote disconnect/connect operations, preventing theft, detecting tampering, detecting reverse voltage, performing prepayment and limiting load, and performing meter validation.
  • Energy Guard Base Assembly 2. Energy Guard Assembly a. Phase Bus Bars and Neutral Bars b. Transition Bars
  • the EG base comprises an enclosure bottom with screws and retaining washers as a locking mechanism for the top cover of EG, which is connected on one side by piano hinges. See FIG. 11.
  • the enclosure bottom provides routing for the customer cables.
  • FIGS. 12 and 13 Three aluminum phase bus bars are placed towards the center of the Energy Guard assembly and staggered. See FIGS. 12 and 13. These provide connection to the customer metering modules by the use of transition bars. A staggered bus bar layout is depicted in FIG. 13. Bus bars are shown in black.
  • the EG preferably comprises 4 neutral bars that form a frame for EG assembly, thereby providing a path for the neutral current. This is shown in FIG. 14.
  • the lug on the cross bar provides the neutral feed from the utility distribution transformer.
  • transition bars complete the mechanical and electrical connection between the customer metering modules and the phase bus bars. See FIG. 15. A transition bar for phase A and C is shown in FIG. 15 A; a transition bar for phase B is shown in FIG. 15B. FIG. 16 shows the transition bars in black.
  • An acceptor module preferably is made of plastic and mechanically accepts the metering modules that can be easily fitted in the EG assembly.
  • Each EG has 4 acceptor modules that are stacked together and can accommodate either 12 two-phase or 8 three-phase metering modules. See FIG. 17.
  • the acceptor module also provides a mechanical route for the motherboard neutral bar which connects to the control module. See FIG. 18.
  • Customer Metering Modules provide metrology required to measure the consumption for a single phase, two phase, or three phase customer.
  • An individual module functions as a complete stand-alone meter that can be tested and evaluated as a separate metering unit.
  • Each module preferably comprises an integrated current sensing and relay module and metrology electronics, and provides a connection between the customer circuit and the phase bus bars.
  • FIG. 19 depicts a preferred integrated current sensing and relay module.
  • FIG. 20 depicts an exploded view of a preferred integrated current sensing and relay module.
  • FIG. 21 shows exploded views of preferred metering modules.
  • FIG. 22 shows the metering modules (shown in black) placed in the EG frame assembly and acceptor module.
  • FIG. 23 shows an exploded view of Energy Guard
  • FIG. 24 shows an exploded view of a preferred EG Assembly and EG Base Assembly.
  • Control Module boxes preferably comprise various PCBs that work concurrently to collect metering data from the individual metering modules and communicate over power lines to transmit this data to a master device, such as a Scan Transponder ("ST").
  • ST Scan Transponder
  • FIG. 25 shows a preferred Energy Guard layout for this embodiment.
  • Each customer line has a corresponding Metering Module (PCB 203 and PCB 204, discussed below) (schematics shown in FIGS. 26 and 27).
  • PCB 203 and PCB 204 discussed below
  • a Back Place Board 2510 shown in FIG. 25 (PCB 234; see FIG. 28 for construction diagram and schematic) is the common bus that routes signals within the EG.
  • the Control Module 2520 comprises a Power Board (PCB 210; see FIG. 29 for schematic) is the power supply board that also has the PLC transmit and receive circuitry on it.
  • the Power Board provides power to the CPU board and the electronics of 203 boards.
  • the Control Module 2520 also comprises an I/O Extension Board (PCB 230; see FIG. 30 for schematic) is a board with several I/O extension options that enable communication from Metering Modules to the CPU board.
  • Control Module 2520 also comprises a CPU Board (PCB 202; see FIG. 31 for schematic), which has a Digital Signal Processing (DSP) processor on board.
  • DSP Digital Signal Processing
  • Control Module 2520 comprises a routing board (PCB 235; see FIG. 32 for schematic) with traces and a header with no electronic components on it.
  • Each Customer Display Module (CDM) 2530 is installed at the customer's premises and can bidirectionally communicate with the EG installed at the distribution transformer serving the customer. Two-way PLC enables utility- customer communication over low voltage power lines and allows the utility to send regular information, warnings, special information about outages, etc. to the customer.
  • Each CDM 2530 comprises a selected combination of metering and power supply along with PLC circuitry on the same board (PCB 240; see FIG. 33 for schematic).
  • Each CDM preferably also has a 9-digit display board (PCB 220; see FIG. 34 for schematic). This display communicates with EG and shows information about consumption, cautions, warnings, and other utility messages.
  • the Energy Guard implements Fast Fourier Transform (FFT) on the PLC communication signal both at the ST and the meter, and for metering purposes performs detailed harmonic analysis.
  • FFT Fast Fourier Transform
  • the Control Module 2520 comprises power supply and PLC circuitry (PCB 210; see FIGS. 25 and 29); I/O extension (PCB 230; see FIG. 30) and CPU board named D Meter (PCB 202; see FIG. 31).
  • the power supply supplies power to the D meter and I/O extension and contains the PLC transmitter and receiver circuitry.
  • PCB 235 provides a trace routing and header connection between various boards.
  • the Metering Module may have two versions: 2-phase or 3-phase.
  • the 2- phase version can be programmed by software to function as a single 2-phase meter or two 1 -phase meters.
  • the 2-phase version comprises a B2 meter (PCB 203 schematic shown in FIG. 26), whereas the 3-phase version comprises a B3 meter (PCB204 schematic shown in FIG. 27).
  • the B meters act as slaves to the D meter in Control
  • the D and B meters can communicate via a serial ASCII protocol.
  • the various B meters are interconnected via BPB 2510 to 2520 that provides power, a I Hz reference and serial communications to the D meter.
  • the preferred DSP engine for the B meter is the Freescale 56F8014VFAE chip.
  • the preferred microprocessor used for implementing the CPU on the D meter is one among the family of ColdFire Integrated Microprocessors, MCF5207. The use of a specific processor is determined by RAM and Flash requirements dictated by the meter version.
  • a separate power supply and LCD board complete the electronic portion of the D meter as a product.
  • the D meter is also a 3 -phase meter and measures the total transformer output on which the EG is installed. As an anti-theft feature, this total is compared with the total consumption reported by the various B meters.
  • the signal streams constituency is as follows:
  • B2 Two voltage, Two current, and No Power Line Carrier (PLC) Channel.
  • B3 Three voltage, Three current, and No PLC Channel.
  • Each stream has an associated circuit to effect analog amplification and antialiasing.
  • a Phase Locked Loop PLL
  • PLL Phase Locked Loop
  • VCO Voltage Controlled Oscillator
  • Each metering and communication channel preferably comprises front-end analog circuitry followed by the signal processing.
  • Unique to the analog circuitry is an anti-aliasing filter with fixed gain which provides first-order temperature tracking, hence eliminating the need to recalibrate meters when temperature drifts are encountered. This is discussed next, and then a preferred signal processing implementation is discussed. Voltage and Current Analog Signal Chain
  • the analog front-end for voltage (current) channels comprises voltage (current) sensing elements and a programmable attenuator, followed by an antialiasing filter.
  • the attenuator reduces the incoming signal level so that no clipping occurs after the anti-aliasing filter.
  • the constant gain anti-aliasing filter restores the signal to full value at the input of the Analog to Digital Converter (ADC).
  • ADC Analog to Digital Converter
  • the anti-aliasing filter cuts off frequencies above 5 kHz. The inputs are then ted into the ADC which is a part of the DSP. See FTG. 35, which is a block diagram of a preferred analog front-end for metering.
  • a typical implementation would include a Programmable Gain Amplifier (PGA) followed by a low gain anti-aliasing filter
  • the invention implements a programmable attenuator followed by a large fixed-gain filter.
  • the implementation of both the anti-aliasing filters on a single chip is the same using the same Quad Op Amps along with 25 ppm resistors and NPO/COG capacitors.
  • This unique implementation by pairing the anti-aliasing filters ensures that the phase drifts encountered in both voltage and current channels are exactly identical and hence accuracy of the power calculation (given by the product of V and I) is not compromised. This provides a means for both V and I channels to track temperature drifts up to first order without recalibrating the meter.
  • FIG. 36 is a block diagram of the PCB 202 board; the functions of each block will be apparent to those skilled in the art.
  • FIG. 36 shows a preferred DSP implementation.
  • This embodiment preferably uses a PLL to lock the sampling of the signal streams to a multiple of the incoming A/C line frequency.
  • the sampling is at a rate asynchronous to the power line.
  • the VCO In the D meter, there is a VCO at 90-100 MHz which is controlled by the DSP engine via two PWM modules.
  • the VCO directly drives the system clock of the DSP chip (disabling the internal PLL), so the DSP becomes an integral part of the PLL. Locking the system clock of the DSP to the power line facilitates the alignment of the sampling to the waveform of the power line.
  • the phase detector should function so as to respond only to the fundamental of the incoming 60Hz wave and not to it harmonics.
  • FIG. 37 is a block diagram of this preferred DSP implementation.
  • a DSP BIOS or voluntary context switching code provides three stacks, each for background, PLC communications and serial communications.
  • the small micro communicates with the DSP using a I2C driver.
  • the MSP430F2002 integrated circuit measures the power supplies, tamper port, temperature and battery voltage.
  • the tasks of the MSP430F2002 include: j. maintain an RTC; ii. measure the battery voltage; iii. measure the temperature; iv. measure the +U power supply; v. reset the DSP on brown out; vi. provide an additional watchdog circuit; and vii. provide a 1 -second reference to go into the DSP for a time reference to measure the 1 -second reference against the system clock from the VCO.
  • a typical installation consists of multiple EGs and STs communicating over the power lines.
  • the D meter communicates bi-directionally with a remotely located Scan Transponder through the distribution transformer.
  • This embodiment uses a 10-25 kHz band for PLC communication.
  • the PLC signal is sampled at about 240 kHz (212 * 60), synchronous with line voltage, following which a Finite Impulse Response (FIR) filter is applied to decimate the data.
  • FIR Finite Impulse Response
  • Ibis embodiment preferably implements a unique technique for robust and reliable communication. This is done by injecting PLC signals at frequencies that are half odd harmonics of the line frequency (60Hz). This is discussed below, for an embodiment using a typical noise spectrum found on AC lines in the range 12-12.2 kHz.
  • FIG. 39 illustrates injecting PLC signals at half-odd harmonics of 60 Hz.
  • the data bits reside in the bin corresponding to the 201.5th and 202.5th harmonic of 60 Hz in FIG. 39.
  • the algorithm considers these two bins of frequencies and compares the amplitude of the signal in the two to determine 1 or 0.
  • This FSK scheme uses two frequencies and yields a data rate of 30 baud.
  • QFSK which uses 4 frequencies, can be implemented to yield 60 baud.
  • both STs and D meters When traversing through transformers, both STs and D meters preferably perform FFT on the PLC and data signals every 30 Hz in a 10-25 JcHZ range. Because the Phase Lock Loops (PLLs) implemented in both the ST and the D meter are locked to the line, the data frames are synchronized to the line frequency (60 Hz) as well. However, the data frames can shift in phase due to:
  • the signal to noise ratio (SNR) is maximized when the meter data frame and ST data frames are aligned close to perfection. From a meter's standpoint, this requires receiving PLC signal from all possible STs that it can "hear,” decoding the signal, checking for SNR by aligning data frames, and then responding to the ST that is yielding maximum SNR.
  • FIG. 40 depicts the 12 possible ways in which the FFT frame received by the meter can be out of phase with ST FFT frame. Dotted lines correspond to a 30 degree rotation accounting for a delta transformer in the signal path between ST and the meter.
  • the D meter decodes signals with misaligned data frames, there is energy that spills over into the adjacent (half-odd separated) frequencies. If the signal level that falls into the "adjacent" frequency bin is less than the noise floor, the signal can be decoded correctly. However, if the spill-over is more than the noise floor, the ability to distinguish between 1 and 0 decreases, and hence the overall SNR drops, resulting in an error in decoding. In conclusion: a. If the frames are misaligned, smearing of data bits occurs and the SNR degrades. b.
  • the meter locks until a significant change in SNR ratio is encountered by the meter, in which case the process repeats.
  • the D meter also is responsible for collecting the metering information from the various B meters via PCB 234.
  • Each data stream in the meters has an associated circuit to effect analog amplification and anti-aliasing.
  • Each of the analog front end sections has a programmable attenuator that is controlled by the higher level code.
  • the data stream is sampled at 60 kHz (2 10 * 60) and then an FIR filter is applied to decimate the data stream to ⁇ 15 kHz (2 8 * 60). Preferred filter specifications are shown in the table below and FIG. 41.
  • a 256-point complex FFT can be performed on every phase of the decimated data stream. This yields 2 pairs of data streams: a real part, which is the voltage, and an imaginary part, which is the current. This approach requires a 256 complex FFT every 16.667 milliseconds.
  • Vn and In correspond to the fundamental of the first cycle
  • V 21 and I 21 to the first harmonic of the first cycle, etc., as shown in FIG. 42, which depicts FFT frames for voltage, indicating the harmonics.
  • the imaginary part of voltage is the measure of lack of synchronization between the PLL and the line frequency.
  • the calculations are done in the time domain.
  • the FFT functionality offers the flexibility to calculate metering quantities either using only the fundamental or including the harmonics.
  • the metering quantities are calculated as:
  • V x RMS V x RMS ; forN cycles.
  • THD Total Harmonic Distortion
  • V mn (l mn ) is the m th harmonic from the n th cycle obtained from the FFT,
  • the customer display module is installed at the customer premises, communicates with Energy Guard near the transformer, and comprises: PCB 240, power supply and PLC circuitry (see FIG. 33); and PCB 220, LCD display (see FIG. 34).
  • the customer display unit installed at customer's residence is a bidirectional PLC unit that communicates with EG. Forjexample, not only can the utility send messages, the customer can also request a consumption verification with the EG installed at the pole.
  • QLC LCM Load Control Module
  • FUSES _PWRTE_OFF ; Disable power-up timer FUSES _WDT_ON ; Watchdog Timer Enabled FUSES _RC_OSC ; Oscillator RC
  • LCM_base_addr equ 16 Address of first LCM Ram_start equ 02Oh ; Beginning of available RAM
  • Timer 0 uses inst clock
  • Clk_wait_flag equ 7 indicates which clock edge we are waiting for Global_cmd_flag equ 6 ; Processing global command scratch ds 1 ; Work register Timeout_ctr ds 2 ; Counter for pulse duration Millisecs ds 1 ; Counter for pulse duration milliseconds
  • Jz lnit_state If zero, done mov W,FSR ; get pointer and W,#7fH ; look at 7 LSB's jnz :clr_loop ; Not end of segment, continue add FSR,#20h ; Point to next segment jmp :clr_loop ; Not last segment, continue Jnit_state setb Status_LSB.CPU_reset_flag , Indicate CPU reset setb Status_LSB.Needj>aram_reftesh_flag , Indicate parameter refresh needed mov comm_port,#Init_comm_port_value ; initialize comm port state mov Comm_state,#Edge_wait mov Comm_bit_count,#Nurn_start_bits ; Initialize fast comm state machine clr PORTB clr PORTC jmp Main_loop ; start running main program
  • Jz See_edge_one if zero, looking for a 1 Jb Input_hold.data_in,Set_edge_wait ; Looking for 0, reset bit count if 1 jmp Comm ret ; done See_edge_one jnb Input_hold.data_in,Set_edge_wait ; looking for 1, reset if 0 mov Wstate,#Rcv_addr ; First word is address mov T ⁇ ar,#01 fh ; In it parity jmp Rev next word
  • Rcv_tpar mov W/Tpar Get result of parity calculations jnz Pari ⁇ y_error ; If not 0, parity error j «np Set_rcv_stop ; set up to receive stop bit Comm transmit word handler routines
  • Send_addr mov Wstate,#Send cmd> point to next word routine mov W,PIC_addr ; get address jmp Send_next_word
  • Send_cmd mov Wstate,#Send_value> point to send value jnb Command.4, Value _is next ; Is it fast read command? mov Wstate,#Send_regJD> ; point to next word routine
  • Send_reg_ID mov Wstate,#Send_value> point to next word routine mov W,Register_ID ; get Register ID jmp Send_next_word
  • SendJTpar mov Wstate,#Send stop point to next word routine mov W.Tpar ; get transverse parity jmp Send_next_word
  • Reg 30 Serial number call serno mov comm_buf+3 , W call semo+1 mov comm_buf+2 :> W call serno+2 mov comm_buf+ 1 ,W call serno+3 mov comm_buf,W jmp Setup_reply
  • Reg 28 Parameter reg mov Comm_buf,Parameter reg mov Comm_buf+1 ,Parameter_reg+l mov Comm_buf+2,Parameter_reg+2 mov Comm_buf+3 ,Parameter_reg+3 jmp Setup_reply
  • Reset_statusJ jits mov Comm_bit_count,#5 ; need to shift buffer by 5 bits
  • MSB mov Tpar,#lfh Initialize parity word mov Comm_state,# Send_edge ; Go to send_edge state mov Wstate,#Send_addr ; Point to next routine mov Comm_bit_count,#Nurnjstart_bits ; Init number of bits jmp Cotnin ret
  • Parity error setb status_LSB.Parity_err_flag Indicate parity error Set_edge_wait mov Comm_state,#Edge_wait ; Go to edge wait state mov Comm_bit_count,#Num__start_bits : Init number of bits jmp Comm_ret
  • Comm_buf+1[3] Bit map of output states - MSB first bits 23-18: Unused bits 17-0: Outputs 18-1
  • Update_outputs mov W,Comm_buf+3 get lsbs and W,#03h ; only need 2 bits mov Tem ⁇ ,W add Temp,W ; Shift into bits 1 and 2 (Xl and X2) mov W 3 PORTA ; Get present status of port A pins and W,#0f9h ; clear output control bits or W,Temp ; Set desired output state mov PORTA 5 W ; output new value rr comm_buf+l rr comm_buf+2 rr comm_buf+3 rr comm_buf+-l rr comm_buf+2 rr comm_buf+3 ; shift buffer left 2 bits mov PORTB,comm_buf+2 mov PORTC,comm_buf+3 mov !PORTA,#init_TRISA mov !PORTB,#init_TRISB mov !PORTC,#init_
  • PICxmitBuf.bits.bufLong[0] PICxmitBuf.bits.bufLong[0] « 1; if (PICxmitBuf.bits.bufLong[l] and 0x80000000)
  • PICxmitBuf.bits.bufLong[l] PICxmitBuf.bits.bufLong[l] « 1; if (PICxmitBuf.bits.bufLong[23 and 0x80000000)
  • PICxmitBuf.bits.bufLong[2] PICxmitB ⁇ f.bits.bufLong[2] « 1; /* Shift 96-bit buffer */
  • PICrcvBuf.bits.bufLong[0] PICrcvBuf.btts.bufLong[0] « 1 ; if (PICrcvBuf.bits.bufLong[l] and 0x80000000)
  • PlCrcvBuf.bits.bufLong[l] PICrcvBuf.bits.bufLong[l] « 1; if (PlCrcvBuf.bits.bufLong[2] and 0x80000000)
  • ROXL.W -(AO) rotate left and decrement pointer */ " ROXL.W -(AO)", /* rotate left and decrement pointer */
  • PICrcvBuf.bits.buffiytefl 1] (PICrcvBuf.bits.bufByte[l 1] and Oxfe)
  • PIC_serial_status idle; break; case sending_start:
  • PlC_serial_status idle; ⁇ ⁇
  • PIC_status[i].clear__pulse_regs TRUE; PIC_status[i] .get_status ⁇ TRUE;
  • P ⁇ C_stat ⁇ s[O].PIC_addr MC5_MUX_PIC_ADDR; /* If MC5, add PDM PIC(s) to PIC table */ if(int_configltmessg.configLTM[PULSEl].accum)
  • PIC_addr work_PIC_addr++; /* LCM's */
  • PIC_status[num_PICs++].PIC_addr work_PIC_add ⁇
  • ATM_work ATM_work « 1 ; ⁇
  • PIC_status[i].reply_wait_iimit DIRECT_PIC_WAIT_LIMIT; else
  • PIC_status[i].reply_wait_limit BUFFERED_PIC_WAIT_LIMIT; /telse
  • (MUX_control.rcv_mask I MUX_control.last_rcv_mask))
  • PIC_serial_status idle; if (PIC_serial_status — idle) ⁇ if(!WDTpu!seSec)
  • RCV_DATA_RDY;
  • ATM_control.result_flags PICrcvBuf.fiags; if(rcv_buf_err)
  • ATM_control.optimum_cap_code PICrcvBuf.command data and ATM_RC_CAP_MASK;
  • ATM_control.optimum_reading PICrcvBuf .comraand_data » 16; ATM_control.result_flags
  • (PICrcvBuf.command_data and OxeOOO);
  • ATM_control.ei ⁇ or_flag TRUE; ⁇ if(ATM_control.optimum_reading ⁇ ATM_MIN_READING)
  • ATM_control.result_flags 0x1000; /* Indicate reading too low */
  • ATM_coiitrol.done__flag TRUE; ⁇ if (MUX_control .active_flag)
  • MUX_control.resuIt_flags PICrcvBuf.flags; if (rcv_buf_err)
  • MUX_control.last_xmit_mask PICrcvBuf.command_data and Oxft;
  • MUX_control.last_rcv_mask (PICrcvBuf.command_data » 8) and Oxff; ⁇
  • MUX_control.active_flag FALSE
  • MUX_control.done_flag TRUE
  • pulseData[workjpulse_index].ID_buffer[i] *work_char_ptr; i++; work_charj>tr-H-; ⁇ if (j>5)
  • ⁇ accumXfer.low pulseData[vvork_pulse_index].reading;
  • mapping for pulse 1 thru 48 is M1Q13..M24Q13, M1Q14..M24Q14 */
  • PIC_status[rcv_P ⁇ C_index].updatejparameter TRUE; /* check status flags */
  • PICxmitBuf.PIC_addr GLOBAL_PIC_ADDR;
  • PIC_serial_status do_send_ctnd; I* Start U ⁇ RT */
  • PlCxmitBuf.PlC_addr ATM_control.ATM_number + ATM_BASE_ADDR; switch (ATM control.operation)
  • PICxmitBuf.command_data ATM_control.start_ca ⁇ _code and ATM_RC_CAP_MASK; ' ' ' ' ' ' ' ' PICxmitBuf.command_data
  • ATM_PRESET_CODE;
  • ATM_control.state DO_PRESET; break; case DOJALIQN: .
  • PlCxmitBuf.command WR1TE_REGISTER;
  • PICxmitBuf.regJD CONTROLJREG; if (ATM_control.start_cap_code > ATM_control.end_cap code)
  • ATM_control.end_cap_code ATM control.start cap code
  • PICxmitBuf.command_data ATM_control.start_ca ⁇ _code and ATM_RC_CAP_MASK;
  • PICxmitBuf.command_data (PICxmitBuf.command_data « 12 )
  • PICxmitBuf.command_data (PICxmitBuf.command_data « 12 )
  • ATM_control.align_timer * ((ATM_DISG_TIME + ATM_MEAS TIME + 4) * (1.25 / 62.5));
  • ATM_controI.align_timer + 13; /* Time in 1/64 sec to wait before checking result */
  • PICxmitBuf.comtnand_data ATM_control.optimum_cap_code and ATM_RC_CAP_MASK;
  • PlCxmitBuf.command WRITE_REG1STER
  • PlCxmitBuf.re&JD OUTPUT_REG
  • PICxmitBuf.command__data * ATM_controhoptimum_cap_code and ATM_RC_CAP_MASK;
  • ATM_control.active_flag FALSE; break; ⁇ if (ATM_coni ⁇ ol.active flag)
  • PIC_serial_status do_send_cmd; /* Start UART */
  • ATM_control.done_fiag - TRUE; ATM_control.active_flag FALSE;
  • P ⁇ CxmitBuf.bits.buf ⁇ yte[O] ((MUX_control.rcv_mask and 0x03) « 5)
  • MUX_control.last_xmit_mask MUX_control.xmit_mask
  • MUX_control.last_rcv_mask MUX_control.rcv_mask
  • r4UX_control.done_flag TRUE;
  • PIC_wait__limit BUFFERED_PIC_WAIT_LIMIT; else #endif
  • ST5_PlC_delay_ctr ST5_PIC_DELAY; /* Slow down routine communications in the ST5 */ #else
  • ⁇ - need_pulse_read FALSE
  • PICxmitBuf.command READ_REG ⁇ STER
  • PlCxmitBuf.reg_ID VERS_REG; format_xmit_buffer();
  • PICxmitBuf.reg_ID. SERNO_REG; format_xm it_buff er();
  • PICxmitBuf.command_data 0x0115230d; # ⁇ ndif
  • PICxmitBuf.command_data 0x0c007080; /* 32 bps, no wake-up */
  • PICjimitBuf.command_data 0x02030080; /* 205 bps, no wake-up */
  • PICxmitBuf.commandjiata 0x02030000
  • PICxmitBuf.command_data 0x00000000; ⁇ ⁇ • •
  • PICxmitBuf.command SYSTEM_CONTROL
  • PICxmitBuf.command_data SYSTEM_CONTROL
  • PICxmitBuf.command_data PICxmitBuf.command_data « 16; /* Move status bits to MSb's */
  • PICxmitBuf.reg_ID STATUS_REG; format_xmit_buffer();
  • ⁇ need_pu1se_read FALSE
  • PICxmitBuf.command READ_REGISTER
  • STATUS-REG STATUS-REG
  • PICxmitBuf.command_data READ_ENCODER_ED
  • PICxmitBuf.command_data (PICxmitBuf. command_data « 2) + 1 ; /* lsb turns relay on */ else .
  • PICxmitBuf.command_data (PICxmitBuf.command_data « 2) + 2; /* msb turns relay on */
  • PICxmitBuf.command READ_REGISTER; .
  • PIC_status[current_PIC_index].update_parameter TRUE; ⁇ /endif ⁇
  • PIC_status[rcv_PIC_index] .PIC_data_err_count + 1000; /* Spurious clr cmd */ set_PIC_alarm(PIC_flags_0,PIC_status[rcv_PICJnde ⁇ 3.PIC_addr, PIC_status[rcv_PIC_index].status_reg_value);
  • PICrcvBuf.command_data (PICrcvBuf.comma ⁇ id_data « 2) + (v/orklnt » 3); ⁇ .
  • PICrcvBuf.command_data tempj_command_data
  • PICrcvBuf.flags temp_fJags
  • PlCrcvBitf-bitCount 66; if ((PIC_comm_mon.control_flags and XMIT_D ⁇ TA_RDY) « ⁇ 0)
  • PIC _ ⁇ omm_mon.xmit_buf PICxmitBuf
  • PICrcvBuf.PIC_addr PICxmitBuf.PIC_addr; /* preset address of remote PIC */
  • /* include file at end of mtrsamp to control MC and ST pic chips from mtrsamp interrupt */
  • PIC_status_t typedef enum ⁇ sending_bits, sending_st5_bits, rcving bits, do_PIC_start, sendingJPIC_start, do_send_cmd, sending_start, sending_start_ 1 , sending_stop, waiting_for_start, rcving_stop, idle ⁇
  • DO_PLC_SET SET-ALIGN, WAIT_ALIGN, DO_ATM_DISCONNECT, ATM_DONE
  • typedef struct ⁇ unsigned char PIC_addr; unsigned char command; unsigned char reg_JD; unsigned long command_data; unsigned int flags; int bitCount; union ⁇ unsigned long bufLong[3]; unsigned char buf ⁇ yte[12]; ⁇ bits;
  • MAX_PULSE_PIC_ADDR 15 /* pulse couters are from 0 to 15 */
  • ATM_state_t state unsigned request_flag : 1; unsigned done_flag : 1 ; unsigned errorjflag : 1 ; unsigned active_flag : 1; unsigned int start_cap_code; unsigned int end_cap_code; unsigned int optimum_cap_code; unsigned int optimum_reading; unsigned int xmiMevel; unsigned int couplerjevel; unsigned int result_flags; long int align_timer;
  • addrfn_tbI[GET_FROM_SLAVE][PULSEOUT_STATE] pulseoutaddrfn ;

Abstract

Dans un aspect, l'invention concerne un dispositif qui permet de mesurer la consommation d'électricité et qui comprend : un moyen de déconnexion à distance par une communication via le réseau électrique; un moyen de détection de détournement de ligne électrique; un moyen de détection de fraude; et un moyen de détection de tension inverse. Dans un autre aspect, l'invention concerne un appareil permettant d'effectuer une mesure multivoie de la consommation électrique comprenant : (a) un compteur servant à mesurer la consommation d'électricité pour une pluralité de lignes électriques; (b) un transpondeur servant à transmettre des données reçues du compteur par une communication via le réseau électrique à un ordinateur distant et à transmettre les données reçues de l'ordinateur distant par une communication via le réseau électrique au compteur; et (c) un module de commande de charge servant à activer la connexion et la déconnexion d'une pluralité de relais, chacun de ces relais correspondant à une des lignes électriques.
EP06849894.8A 2005-11-15 2006-11-15 Appareils et procédés pour une mesure multivoie de la consommation électrique Not-in-force EP1960932B1 (fr)

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US73758005P 2005-11-15 2005-11-15
US73937505P 2005-11-23 2005-11-23
US11/431,849 US7539581B2 (en) 2000-02-29 2006-05-09 System and method for on-line monitoring and billing of power consumption
US81390106P 2006-06-15 2006-06-15
PCT/US2006/044762 WO2007094837A2 (fr) 2005-11-15 2006-11-15 Appareils et procédés pour une mesure multivoie de la consommation électrique

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KR101161982B1 (ko) * 2010-09-03 2012-07-03 엘에스산전 주식회사 원격 전기자동차 관리 시스템
PL3107218T3 (pl) * 2015-06-19 2023-10-09 Gwf Ag Sposób i urządzenie do transmisji danych oraz jednostka licznikowa
US10886728B2 (en) * 2018-07-12 2021-01-05 Ovh Circuit implementing an AC smart fuse for a power distribution unit
CN111679112B (zh) * 2020-06-18 2022-06-28 杭州炬华科技股份有限公司 电能表窃电类型判断方法、装置、计算机设备和存储介质
CN113163274B (zh) * 2021-06-24 2021-09-14 深之蓝(天津)水下智能科技有限公司 一种水下机器人通信系统

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EP1960932B1 (fr) 2015-08-12
WO2007094837A3 (fr) 2008-05-02
WO2007094837A2 (fr) 2007-08-23
PL1960932T4 (pl) 2016-03-31
PL1960932T3 (pl) 2016-03-31
CN101351803B (zh) 2010-11-17
ES2554499T3 (es) 2015-12-21
AR057593A1 (es) 2007-12-05
EP1960932A4 (fr) 2012-10-31
CN101351803A (zh) 2009-01-21

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